METHOD OF COOLING A NATURAL GAS FEED STREAM AND RECOVERING A NATURAL GAS LIQUID STREAM FROM THE NATURAL GAS FEED STREAM

Abstract

The invention relates to a method and system for cooling a natural gas feed stream and recovering a natural gas liquid stream from the natural gas feed stream using an expansion-based cooling unit and a natural gas liquid removal unit which are integrated. The integration is done by using (part of) a cooling stream from the expansion-based cooling unit to provide cooling duty to the natural gas liquid removal unit.

Claims

1. A method of cooling a natural gas feed stream and recovering a natural gas liquid stream from the natural gas feed stream, the method comprising: a) operating an expansion based cooling unit, comprising obtaining a cooling stream being derived from the natural gas feed stream, b) operating a natural gas liquid removal unit, comprising passing a feed stream being derived from the natural gas feed stream to a separation unit and obtaining a C.sub.5.sup.+ depleted top stream from the separation unit, wherein the method comprises cooling the C.sub.5.sup.+ depleted top stream in an overhead condenser against at least part of the cooling stream.

2. The method according to claim 1 comprising: a) operating an expansion based cooling unit, comprising a1) obtaining a compressed process stream and a cooling stream from a pressure unit, both the compressed process stream and the cooling stream being derived from the natural gas feed stream, a2) passing the compressed process stream and at least part of the cooling stream to an indirect heat exchanger to cool the compressed process stream against the at least part of the cooling stream to obtain a cooled compressed process stream and a warmed cooling stream, a3) recycling the warmed cooling stream to the pressure unit to be comprised in the compressed process stream and/or the cooling stream, b) operating a natural gas liquid removal unit, comprising b1) passing a feed stream being derived from the natural gas feed stream to a separation unit and obtaining the natural gas liquid stream from a lower part of the separation unit and a C.sub.5.sup.+ depleted top stream from the separation unit, b2) cooling the C.sub.5.sup.+ depleted top stream thereby obtaining a cooled C.sub.5.sup.+ depleted top stream, b3) passing the cooled C.sub.5.sup.+ depleted top stream to a separation vessel, thereby obtaining a further gaseous top stream and a liquid bottom stream, b4) feeding back the liquid bottom stream to an upper part of the separation unit as a reflux stream, b5) passing the further gaseous top stream to the expansion based cooling unit, wherein the method comprises cooling the C.sub.5.sup.+ depleted top stream in an overhead condenser against at least part of the cooling stream.

3. The method according to claim 1, further comprising: expanding the natural gas feed stream in an inlet expander to obtain an expanded natural gas feed stream and passing the expanded natural gas feed stream to the separation unit thereby providing the feed stream to the separation unit.

4. The method according to claim 3, wherein cooling the C.sub.5.sup.+ depleted top stream in the overhead condenser is done against the entire cooling stream or part of the cooling stream, thereby obtaining a warmed cooling stream, the method further comprising the steps of: passing the further gaseous top stream to the expansion based cooling unit comprises combining the further gaseous top stream with the warmed cooling stream to obtain a combined stream and passing the at least part of the cooling stream to the indirect heat exchanger in a2) is done by passing the combined stream to the indirect heat exchanger.

5. The method according to claim 1, wherein: a1) further comprises passing the warmed further gaseous top stream to the pressure unit to be part of the compressed process stream and/or the cooling stream; a2) further comprises splitting the cooling stream in a first cooling stream portion and a second cooling stream portion, wherein the at least part of the cooling stream passed to the indirect heat exchanger is formed by the first cooling stream portion; and wherein cooling the C.sub.5.sup.+ depleted top stream in the indirect heat exchanger is done against the second cooling stream portion, thereby obtaining a warmed second cooling stream portion.

6. The method according to claim 1, further comprising the steps of: cooling the natural gas feed stream in an inlet heat exchanger against the further gaseous top stream obtained from the separation vessel to obtain a cooled natural gas feed stream and a warmed further gaseous top stream, passing the cooled natural gas stream to the separation unit thereby providing the feed stream.

7. The method according to claim 1, wherein the warmed cooling stream and the warmed second cooling stream portion are passed to a recompression unit.

8. The method according to claim 1, wherein cooling the C.sub.5.sup.+ depleted top stream is done in the overhead condenser against the cooling stream, thereby obtaining a warmed cooling stream, and wherein: a1) further comprises feeding the natural gas feed stream and a recycle stream to the pressure unit, and wherein the method comprises the steps of: passing the warmed cooling stream to the separation unit thereby providing the feed stream to the separation unit; passing the further gaseous top stream obtained in b3) to the indirect heat exchanger thereby providing the at least part of the cooling stream which is passed to the indirect heat exchanger in a2); and passing the warmed cooling stream which is obtained in a2) to a recompression unit to obtain the recycle stream.

9. A system for cooling a natural gas feed stream and recovering a natural gas liquid stream from the natural gas feed stream, the system comprising an expansion based cooling unit arranged to generate a cooling stream and a natural gas liquid removal unit comprising a separation unit arranged to discharge a C.sub.5.sup.+ depleted top stream, wherein the system further comprises an overhead condenser fluidly connected to the separation unit to receive the C.sub.5.sup.+ depleted top stream and fluidly connected to the expansion based cooling unit to receive at least part of the cooling stream to cool the C.sub.5.sup.+ depleted top stream against the at least part of the cooling stream.

10. The system according to claim 9, comprising an expansion based cooling unit, wherein the expansion based cooling unit comprises: a pressure unit which is arranged to receive at least a recycle stream and generate and discharge a compressed process stream and a cooling stream, an indirect heat exchanger fluidly connected to the pressure unit to receive the compressed process stream and the cooling stream to cool the compressed process stream against the at least part of the cooling stream thereby obtaining a cooled compressed process stream and a warmed cooling stream, the system further comprising a recompression unit being fluidly connected to the expansion based cooling unit to receive and compress at least the warmed cooling stream, the recompression unit being arranged to discharge the recycle stream, which is at least partially derived from the warmed cooling stream, the recompression unit being in fluid communication with the pressure unit, wherein the system further comprises a natural gas liquid removal unit, the natural gas liquid removal unit comprising a separation unit arranged to receive a feed stream and separate the feed stream to obtain and discharge a natural gas liquid stream and a C.sub.5.sup.+ depleted top stream, an overhead condenser fluidly connected to the separation unit to receive the C.sub.5.sup.+ depleted top stream and fluidly connected to the expansion based cooling unit to receive at least part of the cooling stream to cool the C.sub.5.sup.+ depleted top stream against the at least part of the cooling stream thereby obtaining a cooled C.sub.5.sup.+ depleted top stream, and a separation vessel fluidly connected to the overhead condenser to receive the cooled C.sub.5.sup.+ depleted top stream and separate the cooled C.sub.5.sup.+ depleted top stream to obtain and discharge a further gaseous top stream and a liquid bottom stream, wherein the separation vessel is fluidly connected to an upper part of the separation unit to feed back the liquid bottom stream to the upper part of to the separation unit as a reflux stream, wherein the separation vessel is fluidly connected to the expansion based cooling unit.

Description

BRIEF DESCRIPTION OF THE DRAWINGS

[0055] The drawing figures depict one or more implementations in accordance with the present teachings, by way of example only, not by way of limitation. In the figures, like reference numerals refer to the same or similar elements.

[0056] FIG. 1 provides a schematic illustration of an embodiment,

[0057] FIG. 2 provides a schematic illustration of an alternative embodiment, and

[0058] FIG. 3 provides a schematic illustration of yet a further alternative embodiment.

DETAILED DESCRIPTION OF THE INVENTION

[0059] There is provided a method and system for cooling a natural gas feed stream and recovering a natural gas liquid stream from the natural gas feed stream using an expansion based cooling unit and a natural gas liquid removal unit which are integrated. The integration is done by using (part of) a cooling stream from the expansion based cooling unit to provide cooling duty to the natural gas liquid removal unit. Below, different embodiments will be described in more detail, showing that different types of integration are possible.

[0060] According to an embodiment there is provided a method of cooling a natural gas feed stream 1 and recovering a natural gas liquid stream 302 from the natural gas feed stream 1, the method comprising:

[0061] operating an expansion based cooling unit, comprising deriving a process stream 111 and a cooling stream 112 from the natural gas feed stream 1 and cooling the process stream 111 against at least part of the cooling stream, and

[0062] operating a natural gas liquid removal unit, comprising passing a feed stream 301 being derived from the natural gas feed stream 1 to a separation unit 304, the natural gas liquid removal unit comprises passing a reflux stream to an upper part of the separation unit 304 as a reflux stream 308, wherein at least part of the cooling stream 112 is used to provide cooling duty to the natural gas liquid removal unit to obtain the reflux stream.

[0063] The term expansion based cooling unit is used to refer to cooling units in which cooling is achieved by expansion-cooling a first natural gas stream thereby obtaining a cooling stream 112 and wherein the cooling stream 112 is used to cool a further natural gas stream (compressed process stream 111). Both the first and the second natural gas stream are derived from the natural gas feed stream 1. Both the compressed process stream 111 and at least part of the cooling stream 112 are passed to an indirect heat exchanger 120 to cool the compressed process stream 111 against the at least part of the cooling stream 112 to obtain a cooled compressed process stream 121 and a warmed cooling stream 122. The warmed cooling stream 122 is fed back to the pressure unit 110.

[0064] The pressure unit 110 is arranged to discharge the compressed process stream 111 at a relatively high pressure (e.g. above 80, 100 or even 120 bara). Also, the cooling stream 112 is compressed by one or more compressors (optionally having an after-cooler) to a relatively high pressure (e.g. above 80, 100 or even 120 bara) to allow efficient expansion cooling over a valve or expander 114.

[0065] The expansion based cooling schemes as depicted in the figures and explained in the description below show one expansion-cooling stage, but it will be understood that additional expansion-cooling stages may be present in which further split-off streams are obtained and used for cooling. Such additional expansion-cooling stages may be positioned downstream of the expansion-cooling stage shown in the figures.

[0066] It will be understood that variations to the expansion based cooling unit are conceivable. For instance, the cooled compressed process stream 121 may be passed on to a further expansion-cooling stage in which a first part of the cooled compressed process stream 121 is expansion-cooled and used to further cool a remainder of the cooled compressed process stream 121.

[0067] Further equipment, such as an end-flash unit, may be available as will be understood by the skilled person.

[0068] The expansion based cooling unit is arranged to discharge a liquefied natural gas stream. The expansion based cooling unit may be fluidly connected to one or more LNG storage tanks to store the cooled and liquefied natural gas.

[0069] According to the embodiments described in more detail below with reference to the different figures, a natural gas liquid stream 302 is obtained from a natural gas feed stream 1 and a natural gas feed stream 1 is cooled using an expansion based cooling unit. The natural gas liquids may be subject to further processing and separation.

[0070] A pressure unit 110 is provided comprising one or more compressors 113 and optionally one or more intercoolers 115 positioned downstream of the compressor 113. It will be understood that the amount of compressors 113 and aftercoolers 115 shown in the Figures is only by way of example and that there may be provided a plurality of parallel and/or serial positioned (intercooled) compressors. A compressed stream 116 is hereby obtained. The compressed stream 116 may have a pressure above 80 bara, above 100 bara or even above 120 bara.

[0071] The pressure unit 110 may further comprise a splitter 117 to split the compressed stream 116 into a first part referred to as the compressed process stream 111 and a second part which is passed through a valve or expander 114 (optionally being a Joule-Tompson valve) thereby obtaining cooling stream 112. Both the compressed process stream and the cooling stream 112 are derived from the natural gas feed stream 1 as will be explained in more detail below. The splitter 117 may be a controllable splitter to control the relative flow rates of the compressed process stream 111 and the cooling stream 112.

[0072] The embodiment described with reference to FIG. 2 has a different set-up as will be explained in more detail below with reference to FIG. 2.

[0073] The cooling stream 112 is at a lower pressure and at a lower temperature than the compressed process stream 111. For instance, the pressure of the cooling stream 112 may be 60-90 bar lower than the pressure of the compressed process stream 111 and the temperature of the cooling stream 112 may be 50-90 C. lower than the temperature of the compressed process stream 111.

[0074] The expansion based cooling unit further comprises an indirect heat exchanger 120 arranged to receive via a first inlet the compressed process stream 111 and via a second inlet at least part of the cooling stream 112 and allow these streams to exchange heat. It will be understood that although the indirect heat exchanger 120 is schematically shown as a single heat exchanger it may in practice comprise several units positioned parallel and/or in series with respect to each other. The indirect heat exchanger 120 may be any suitable type of indirect heat exchanger, such as a coil wound heat exchanger. The term indirect heat exchanger 120 is used to refer to heat exchangers in which the streams that exchange heat do not mix and are not in direct contact with each other.

[0075] The indirect heat exchanger 120 discharges via a first outlet a cooled compressed process stream 121 and via a second outlet a warmed cooling stream 122. The cooled compressed process stream 121 may be at a slightly lower pressure than compressed stream 116 (e.g. 1-4 bar lower), and may have a temperature below minus 30 C.

[0076] Further provided is a recompression unit 200, which is depicted schematically only. The recompression unit 200 comprises one or more compressors able to receive one or more streams and generate and discharge a recycle stream 201 and pass the recycle stream back to the pressure unit 110. The one or more compressors may be positioned in series and may comprise intercoolers. Furthermore, split off streams may be taken form the recompression unit 200 for other purposes, such as for fuel. The warmed cooling stream 122 is passed to the recompression unit 200 to be recompressed and passed back to the pressure unit 110. It will be understood that the recompression unit 110 may receive additional streams not indicated in the Figures.

[0077] The embodiments further comprise a natural gas liquid removal unit equipped to perform actions b1)-b5) as described above.

[0078] The natural gas liquid removal unit comprises a separation unit 304, an overhead condenser 305 and a separation vessel 307.

[0079] The top of the separation unit 304 is fluidly connected to the separation vessel 307 via the overhead condenser 305. In use, a C.sub.5.sup.+ depleted top stream 303 is obtained from the separation unit 304 and passed to the separation vessel 307 via the overhead condenser 305. The overhead condenser 305 comprises a first inlet to receive the C.sub.5.sup.+ depleted top stream 303 and a first outlet to discharge the cooled C.sub.5.sup.+ depleted top stream 306. The C.sub.5.sup.+ depleted top stream 303 is cooled in the overhead condenser 304, thereby obtaining a cooled C.sub.5.sup.+ depleted top stream 306 which is passed on to the separation vessel 307.

[0080] The bottom of the separation unit 304 comprises an outlet to discharge a natural gas liquid stream 302 from the separation unit 304.

[0081] The separation vessel 307 comprises a top outlet to discharge a further gaseous top stream 309 and a bottom outlet to discharge a liquid bottom stream 308, which bottom outlet is in fluid communication with an upper part of the separation unit 304 to pass back the liquid bottom stream 308 to the separation unit 304, thereby providing a reflux stream.

[0082] The top outlet of the separation vessel 307 is in fluid communication with the expansion based cooling unit to pass the further gaseous top stream 309 to the expansion based cooling unit.

[0083] The overhead condenser 305 further comprises a second inlet to receive at least part of the cooling stream 112 to provide cooling duty to the C.sub.5.sup.+ depleted top stream 303 and a second outlet to discharge the warmed second cooling stream portion 112 or the warmed cooling stream 112 (depending on the embodiment).

[0084] The difference between the different embodiments is mainly in the natural gas liquid removal units, so these will be explained in more detail below with reference to the different Figures.

Embodiment 1FIG. 1

[0085] According to the first embodiment schematically depicted in FIG. 1, the natural gas feed stream 1 is first passed through an inlet heat exchanger 2 to allow the natural gas feed stream 1 to be cooled against the above mentioned further gaseous top stream 309. The inlet heat exchanger 2 is an indirect heat exchanger, comprising a first inlet to receive the natural gas feed stream 1 and a first outlet to discharge a cooled natural gas feed stream 4. The cooled natural gas feed stream 4 may have a temperature in the range of minus 10 C.-minus 30 C., where the natural gas feed stream 1 may have a temperature in the range of 5 C.-25 C.

[0086] The inlet heat exchanger 2 further comprises a second inlet to receive the further gaseous top stream 309 and a second outlet to discharge a warmed further gaseous top stream 310. The first outlet of the inlet heat exchanger 2 is in fluid communication with the separation unit 304 to provide the cooled natural gas feed stream 4 to the separation unit 304, forming the feed stream 301 mentioned above.

[0087] The pressure of the cooled natural gas feed stream 20 as well as the pressure in the separation unit 304 may be in the range of 50-60 bara.

[0088] FIG. 1 further shows that the second outlet of the inlet heat exchanger 2 is in fluid communication with the pressure unit 110 to pass the warmed further gaseous top stream 310 to an inlet of the pressure unit 110 and to compressor 113.

[0089] FIG. 1 further shows a splitter 1121 being in fluid communication with the pressure unit 110 to receive cooling stream 112 and split cooling stream 112 in a first cooling stream portion 112 and a second cooling stream portion 112. The first cooling stream portion 112 is passed to the second inlet of the indirect heat exchanger 120. The second cooling stream portion 112 is passed to the second inlet of the overhead condenser 305. The overhead condenser 305 comprises a second outlet which is in fluid communication with the recompression unit 200 to pass the warmed second cooling stream portion 112 to the recompression unit 200.

[0090] The cooling stream 112 and first and second cooling stream portions 112, 112 may be at a temperature in the range of minus 50 C.-minus 60 C. and at a pressure in the range of 30-50 bara.

Embodiment 2FIG. 2

[0091] According to a second embodiment the natural gas feed stream 1 is passed into the pressure unit 110 together with a recycle stream 201 obtained from the recompression unit 200.

[0092] The pressure unit 110 as schematically depicted in FIG. 2 is a variant to the pressure unit 110 depicted in FIG. 1 and comprises two parallel compressors 113 with associated intercoolers 115 positioned downstream of the respective compressors 113. Again, it will be understood that each compressor 113 as shown in FIG. 2 may in fact be formed by multiple (intercooled) compressors, positioned in series and/or parallel with respect to each other.

[0093] A first compressor 113 is arranged to receive the natural gas feed stream 1, a second compressor 113 is arranged to receive the recycle stream 201. However, upstream of the compressors 113 there may be provided a cross-connection to obtain a split recycle gas stream 118 to be added to the natural gas feed stream 1, thereby allowing to balance the flow rates between the two parallel compressors 113 as well as providing the option to control the composition of the cooling stream 112. Controllable valves (not shown) may be provided to control the flow through the cross-connection 118.

[0094] As mentioned above, the overhead condenser 305 comprises a second inlet to receive at least part of the cooling stream 112. According to the embodiment depicted in FIG. 2 the second inlet is in fluid communication with the pressure unit 110 to receive the full cooling stream 112.

[0095] The overhead condenser 305 allows the at least part of the cooling stream 112 to cool the C.sub.5.sup.+ depleted top stream 303 thereby obtaining a cooled C.sub.5.sup.+ depleted top stream 306 and a warmed cooling stream 112. The overhead condenser 305 comprises a second outlet to discharge the warmed cooling stream 112. The second outlet of the overhead condenser 305 is in fluid communication with a bottom part of the separation unit 304 to provide the separation unit 304 with the feed stream 301.

[0096] The top of the separation vessel 307 is in fluid communication with the second inlet of the indirect heat exchanger 120 to pass the further gaseous top stream 309 (obtained in b3) to the indirect heat exchanger 120 thereby providing the at least part of the cooling stream 112 which is passed to the indirect heat exchanger 120 (as indicated in a2). The second outlet of the indirect heat exchanger 120 is in fluid communication with the recompression unit to pass the warmed cooling stream 122 to the recompression unit 200.

[0097] In this second embodiment schematically depicted in FIG. 2, heavy hydrocarbon separation which takes place in the natural gas liquid removal unit, is done at a relatively low pressure, i.e. after gas expansion in valve or expander 114. The pressure in the separation unit 304 may be in the range of 35-45 bara (which is lower than in the first embodiment).

[0098] The natural gas feed stream 1 being received from a gas conditioning or gas processing section (not shown) is first mixed with a split recycle gas stream 118, compressed to relatively high pressure, e.g. above 80 bara, 100 bara or 120 bar and expanded in valve or expander 114. The relatively cool cooling stream 112 from the valve or expander 114 provides cooling for the overhead condenser 305, before undergoing separation in the natural gas liquid removal unit. The treated gas (top outlet of the separation vessel 307) is allowed to exchange cold with the compressed process stream 111, which is also at a relatively high pressure, i.e. substantially equal to the e.g. 120 bar.

Embodiment 3FIG. 3

[0099] According to a third embodiment the natural gas feed stream 1 is passed into an inlet expander 3 to allow the natural gas feed stream 1 to expand, thereby obtaining an expanded natural gas feed stream 5. The outlet of the inlet expander 3 is in fluid communication with an inlet at of the separation unit 304 to pass the expanded natural gas feed stream 5 to the separation unit, thereby providing the above mentioned feed stream 301 to the separation unit 304.

[0100] The natural gas feed stream 1 is typically received at a temperature between 0 C. and 35 C. and a pressure between 1 and 90 bara. The expanded natural gas feed stream 5 is typically at a temperature between 35 C. and 70 C. and a pressure may be in the range of 30-50 bara.

[0101] The pressure unit 110 is similar as in the first embodiment described above with reference to FIG. 1.

[0102] The C.sub.5.sup.+ depleted top stream 303 obtained from the top of the separation unit 304 is passed to the first inlet of the overhead condenser 305 and the cooling stream 112 is passed to the second inlet of the overhead condenser 305, thereby obtaining a warmed cooling stream 112 from the second outlet of the overhead condenser 305. The second outlet of the overhead condenser 305 is in fluid communication with the second inlet of the indirect heat exchanger 120 to pass the warmed cooling stream 112 to the indirect heat exchanger 120.

[0103] Furthermore, the separation vessel 307 is in fluid communication with the warmed cooling stream 112 to combine the warmed cooling stream 112 with the further gaseous top stream 309 thereby obtaining a combined stream 112 which is passed to the second inlet of the indirect heat exchanger.

[0104] The above embodiments provide the advantage that no external refrigerants are needed including the associated supply and storage costs.

[0105] Embodiment 1 prevents enrichment of C.sub.5.sup.+ liquid in the final LNG stream when compared to the composition exiting the separation unit 304 (being a scrub column), due to treatment taking place before liquefaction.

[0106] Embodiments 2 and 3 provide the advantage that the recycle flows are lower compared to embodiment 1, therefore requiring less power for flash gas recompression and recycling.

[0107] From simulation studies, all 3 embodiments showed a specific power consumption lower than 285 kW/tLNG (11.9 kW/tpd).

[0108] It is noted that the pressure and temperature ranges as mentioned above are based on the use of a scrub column for separation unit 304. Operating conditions may be different for other equipment is used, such as a fractionation column, a flash vessel, an adsorber or a membrane. Embodiments 1, 2 and 3 can treat and liquefy average and rich feed gas effectively and also some lean gas composition. For a very lean feed gas, a different choice might be made for separation unit 304 for the actual separation equipment (a fractionation column, a flash vessel, an adsorber or a membrane) or a combination of equipment to achieve natural gas liquefaction.

[0109] The person skilled in the art will readily understand that many modifications may be made without departing from the scope of the invention. Where the word step(s) or action(s) is used in this text with reference to a method or process, it will be understood that this is not done to imply a specific order (in time). The steps/actions may be applied in any suitable order, including simultaneously. Also, the steps/actions are not limited to the examples provided thereof in the description.